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Subdocument 1 - 10-Q - 10-Q

SPECTRA ENERGY PARTNERS, LP filed this Form 10-Q on 5/10/2017


Document

 
 
 
 
 


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
 
 
 
 
 
FORM 10-Q
 
 
 
 
 
ý
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2017
or
¨
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from                      to                     
Commission file number 1-33556
 
 
 
 
 
http://api.tenkwizard.com/cgi/image?quest=1&rid=23&ipage=11585724&doc=12 
SPECTRA ENERGY PARTNERS, LP
(Exact Name of Registrant as Specified in its Charter)
 
 
 
 
 
Delaware
 
41-2232463
(State or other jurisdiction of incorporation)
 
(IRS Employer Identification No.)
5400 Westheimer Court
Houston, Texas 77056
(Address of principal executive offices, including zip code)
713-627-5400
(Registrant’s telephone number, including area code)
 
 
 
 
 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  ý    No  ¨
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  ý    No  ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer  ý    Accelerated  filer  ¨    Non-accelerated filer  ¨   
Smaller reporting company  ¨ Emerging growth company  ¨
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  ý
At March 31, 2017, there were 309,242,850 common units and 6,311,079 general partner units outstanding.
 
 
 
 
 



SPECTRA ENERGY PARTNERS, LP
FORM 10-Q FOR THE QUARTER ENDED
March 31, 2017
INDEX
 
 
 
 
 
 
Page
 
 
 
 
Item 1.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Item 2.
 
 
 
Item 3.
 
 
 
Item 4.
 
 
 
 
 
 
Item 1.
 
 
 
Item 1A.
 
 
 
Item 5.
 
 
 
Item 6.
 
 
 
 

2


CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION
This document includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements represent management’s intentions, plans, expectations, assumptions and beliefs about future events. These forward-looking statements are identified by terms and phrases such as: anticipate, believe, intend, estimate, expect, continue, should, could, may, plan, project, predict, will, potential, forecast, and similar expressions. Forward-looking statements are subject to risks, uncertainties and other factors, many of which are outside our control and could cause actual results to differ materially from the results expressed or implied by those forward-looking statements. Factors used to develop these forward-looking statements and that could cause actual results to differ materially from those indicated in any forward-looking statement include, but are not limited to:
state, provincial, federal and foreign legislative and regulatory initiatives that affect cost and investment recovery, have an effect on rate structure, and affect the speed at and degree to which competition enters the natural gas and oil industries;
outcomes of litigation and regulatory investigations, proceedings or inquiries;
weather and other natural phenomena, including the economic, operational and other effects of hurricanes and storms;
the timing and extent of changes in interest rates and foreign currency exchange rates;
general economic conditions, including the risk of a prolonged economic slowdown or decline, or the risk of delay in a recovery, which can affect the long-term demand for natural gas and oil and related services;
potential effects arising from terrorist attacks and any consequential or other hostilities;
changes in environmental, safety and other laws and regulations;
the development of alternative energy resources;
results and costs of financing efforts, including the ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings and general market and economic conditions;
increases in the cost of goods and services required to complete capital projects;
growth in opportunities, including the timing and success of efforts to develop U.S. and Canadian pipeline, storage, gathering and other related infrastructure projects and the effects of competition;
the performance of natural gas transmission, storage and gathering facilities, and crude oil transportation and storage;
the extent of success in connecting natural gas and oil supplies to transmission and gathering systems and in connecting to expanding gas and oil markets;
the effects of accounting pronouncements issued periodically by accounting standard-setting bodies;
conditions of the capital markets during the periods covered by forward-looking statements; and
the ability to successfully complete merger, acquisition or divestiture plans; regulatory or other limitations imposed as a result of a merger, acquisition or divestiture; and the success of the business following a merger, acquisition or divestiture.
In light of these risks, uncertainties and assumptions, the events described in the forward-looking statements might not occur or might occur to a different extent or at a different time than Spectra Energy Partners, LP has described. Spectra Energy Partners, LP undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

3


PART I. FINANCIAL INFORMATION
Item 1.    Financial Statements.

SPECTRA ENERGY PARTNERS, LP
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
(In millions, except per-unit amounts)

 
Three Months Ended
March 31,
 
2017
 
2016
Operating Revenues
 
Transportation of natural gas
$
538

 
$
484

Transportation of crude oil
101

 
86

Storage of natural gas and other
61

 
54

Total operating revenues
700

 
624

Operating Expenses
 
 
 
Operating, maintenance and other
227

 
179

Depreciation and amortization
85

 
77

Property and other taxes
56

 
44

Total operating expenses
368

 
300

Operating Income
332

 
324

Other Income and Expenses
 
 
 
Earnings from equity investments
38

 
27

Other income and expenses, net
45

 
20

Total other income and expenses
83

 
47

Interest Expense
56

 
56

Earnings Before Income Taxes
359

 
315

Income Tax Expense
5

 
4

Net Income
354

 
311

Net Income—Noncontrolling Interests
37

 
13

Net Income—Controlling Interests
$
317

 
$
298

Calculation of Limited Partners’ Interest in Net Income:
 
 
 
Net income—Controlling Interests
$
317

 
$
298

Less: General partner’s interest in net income
89

 
69

Limited partners’ interest in net income
$
228

 
$
229

Weighted average limited partner units outstanding—basic and diluted
309

 
285

Net income per limited partner unit—basic and diluted
$
0.74

 
$
0.80

Distributions paid per limited partner unit
$
0.68875

 
$
0.63875





See Notes to Condensed Consolidated Financial Statements.
4


SPECTRA ENERGY PARTNERS, LP
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
(In millions)
 
 
Three Months Ended
March 31,
 
2017
 
2016
Net Income
$
354

 
$
311

Other comprehensive income:
 
 
 
Foreign currency translation adjustments
1

 
11

       Total other comprehensive income
1

 
11

Total Comprehensive Income
355

 
322

Less: Comprehensive Income—Noncontrolling Interests
37

 
13

Comprehensive Income—Controlling Interests
$
318

 
$
309


See Notes to Condensed Consolidated Financial Statements.
5


SPECTRA ENERGY PARTNERS, LP
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)

 
 
March 31,
2017
 
December 31,
2016
ASSETS
 
 
 
 
Current Assets
 
 
 
 
Cash and cash equivalents
 
$
282

 
$
216

Receivables, net
 
339

 
380

Inventory
 
40

 
40

Fuel tracker
 
7

 
6

Other
 
17

 
18

Total current assets
 
685

 
660

Investments and Other Assets
 
 
 
 
Investments in and loans to unconsolidated affiliates
 
1,200

 
1,127

Goodwill
 
3,234

 
3,234

Other
 
98

 
108

Total investments and other assets
 
4,532

 
4,469

Property, Plant and Equipment
 
 
 
 
Cost
 
20,735

 
19,958

Less accumulated depreciation and amortization
 
3,940

 
3,866

Net property, plant and equipment
 
16,795

 
16,092

Regulatory Assets and Deferred Debits
 
409

 
385

Total Assets
 
$
22,421

 
$
21,606


See Notes to Condensed Consolidated Financial Statements.
6


SPECTRA ENERGY PARTNERS, LP
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)
 
 
March 31,
2017
 
December 31,
2016
LIABILITIES AND EQUITY
 
 
 
 
Current Liabilities
 
 
 
 
Accounts payable
 
$
486

 
$
441

Commercial paper
 
1,051

 
574

Taxes accrued
 
59

 
76

Interest accrued
 
43

 
79

Current maturities of long-term debt
 
415

 
416

Other
 
145

 
193

Total current liabilities
 
2,199

 
1,779

Long-term Debt
 
6,212

 
6,223

Deferred Credits and Other Liabilities
 
 
 
 
Deferred income taxes
 
43

 
42

Regulatory and other
 
154

 
158

Total deferred credits and other liabilities
 
197

 
200

Commitments and Contingencies
 


 


Equity
 
 
 
 
Partners’ Capital
 
 
 
 
Common units (309.2 million and 308.4 million units issued and outstanding at March 31, 2017 and December 31, 2016, respectively)
 
11,703

 
11,650

General partner units (6.3 million units issued and outstanding at March 31, 2017 and December 31, 2016)
 
481

 
452

Accumulated other comprehensive loss
 
(44
)
 
(45
)
Total partners’ capital
 
12,140

 
12,057

Noncontrolling interests
 
1,673

 
1,347

Total equity
 
13,813

 
13,404

Total Liabilities and Equity
 
$
22,421

 
$
21,606


See Notes to Condensed Consolidated Financial Statements.
7


SPECTRA ENERGY PARTNERS, LP
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
(In millions)

 
 
Three Months Ended
March 31,
 
 
2017
 
2016
CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
 
Net income
 
$
354

 
$
311

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
 
Depreciation and amortization
 
85

 
79

Deferred income tax expense
 
1

 
1

Earnings from equity investments
 
(38
)
 
(27
)
Distributions from equity investments
 
27

 
26

Other
 
(65
)
 
(93
)
Net cash provided by operating activities
 
364

 
297

CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
 
Capital expenditures
 
(738
)
 
(468
)
Investments in and loans to unconsolidated affiliates
 
(70
)
 
(27
)
Purchase of intangible, net
 

 
(48
)
Distributions from equity investments
 
11

 
39

Purchases of held-to-maturity securities
 
(4
)
 
(11
)
Proceeds from sales and maturities of held-to-maturity securities
 
3

 
3

Purchases of available-for-sale securities
 
(68
)
 
(161
)
Proceeds from sales and maturities of available-for-sale securities
 
76

 
163

Other changes in restricted funds
 
2

 
4

Other
 

 
(2
)
Net cash used in investing activities
 
(788
)
 
(508
)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
 
Payments for the redemption of long-term debt
 
(10
)
 

Net increase in commercial paper
 
477

 
330

Distributions to noncontrolling interests
 
(12
)
 
(7
)
Contributions from noncontrolling interests
 
290

 
95

Proceeds from the issuances of units
 
39

 
82

Distributions to partners
 
(294
)
 
(243
)
Net cash provided by financing activities
 
490

 
257

Net increase in cash and cash equivalents
 
66

 
46

Cash and cash equivalents at beginning of period
 
216

 
168

Cash and cash equivalents at end of period
 
$
282

 
$
214

Supplemental Disclosures
 
 
 
 
Property, plant and equipment non-cash accruals
 
$
261

 
$
142




See Notes to Condensed Consolidated Financial Statements.
8


SPECTRA ENERGY PARTNERS, LP
CONDENSED CONSOLIDATED STATEMENTS OF EQUITY
(Unaudited)
(In millions)

 
Partners’ Capital
 
Noncontrolling Interests
 
Total
 
Common
 
General
Partner
 
Accumulated Other
Comprehensive Income (Loss)
December 31, 2016
$
11,650

 
$
452

 
$
(45
)
 
$
1,347

 
$
13,404

Net income
228

 
89

 

 
37

 
354

Other comprehensive income

 

 
1

 

 
1

Attributed deferred tax benefit

 
20

 

 
11

 
31

Issuances of units
38

 
1

 

 

 
39

Distributions to partners
(213
)
 
(81
)
 

 

 
(294
)
Contributions from noncontrolling interests

 

 

 
290

 
290

Distributions to noncontrolling interests

 

 

 
(12
)
 
(12
)
March 31, 2017
$
11,703

 
$
481

 
$
(44
)
 
$
1,673

 
$
13,813

December 31, 2015
$
10,527

 
$
336

 
$
(50
)
 
$
533

 
$
11,346

Net income
229

 
69

 

 
13

 
311

Other comprehensive income

 

 
11

 

 
11

Attributed deferred tax benefit

 
10

 

 
2

 
12

Issuances of units
80

 
2

 

 

 
82

Distributions to partners
(182
)
 
(61
)
 

 

 
(243
)
Contributions from noncontrolling interests

 

 

 
95

 
95

Distributions to noncontrolling interests

 

 

 
(7
)
 
(7
)
March 31, 2016
$
10,654

 
$
356

 
$
(39
)
 
$
636

 
$
11,607




See Notes to Condensed Consolidated Financial Statements.
9


SPECTRA ENERGY PARTNERS, LP
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
1. General
The terms “we,” “our,” “us” and “Spectra Energy Partners” as used in this report refer collectively to Spectra Energy Partners, LP and its subsidiaries unless the context suggests otherwise. These terms are used for convenience only and are not intended as a precise description of any separate legal entity within Spectra Energy Partners.
Nature of Operations. Spectra Energy Partners, through its subsidiaries and equity affiliates, is engaged in the transmission, storage and gathering of natural gas and the transportation and storage of crude oil through interstate pipeline systems. We are a Delaware master limited partnership.
On February 27, 2017, Enbridge Inc. (Enbridge) and Spectra Energy Corp (Spectra Energy) completed a stock-for-stock merger transaction (the Merger) pursuant to which Spectra Energy merged with and into a direct, wholly owned subsidiary of Enbridge, with Spectra Energy continuing as the surviving corporation and a wholly owned subsidiary of Enbridge, and each outstanding share of common stock of Spectra Energy was automatically converted into, and became exchangeable for, 0.984 of Enbridge common share. As a result of the Merger, we became an indirect subsidiary of Enbridge through Enbridge’s ownership of Spectra Energy. As of March 31, 2017, Enbridge and its subsidiaries collectively owned a 75% ownership interest in us (a 73% limited partner interest and a 2% general partner interest), together with 100% of our incentive distribution rights, and the remaining 25% limited partner interest was publicly owned.
Basis of Presentation. The accompanying Condensed Consolidated Financial Statements include our accounts and the accounts of our majority-owned subsidiaries, after eliminating intercompany transactions and balances. These interim financial statements should be read in conjunction with the consolidated financial statements included in our Annual Report on Form 10-K, for the year ended December 31, 2016, and reflect all normal recurring adjustments that are, in our opinion, necessary to fairly present our results of operations and financial position. Amounts reported in the Condensed Consolidated Statements of Operations are not necessarily indicative of amounts expected for the respective annual periods.
Enbridge and its affiliates are solely responsible for providing the employees and other personnel necessary to conduct our operations. Our costs of doing business have been reflected in our financial accounting records for the periods presented. These costs include direct charges and allocations from Enbridge and its affiliates for business services, such as payroll, accounts payable and facilities management; corporate services, such as finance and accounting, legal, human resources, investor relations, public and regulatory policy, and senior executives; and pension and other post-retirement benefit costs.
Use of Estimates. To conform with generally accepted accounting principles (GAAP) in the United States, we make estimates and assumptions that affect the amounts reported in the Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements. Although these estimates are based on our best available knowledge at the time, actual results could differ.

10


2. Business Segments
We manage our business in two reportable segments: U.S. Transmission and Liquids. The remainder of our business operations is presented as “Other,” and consists of certain corporate costs.
Our chief operating decision maker regularly reviews financial information about both segments in deciding how to allocate resources and evaluate performance. There is no aggregation of segments within our reportable business segments.
The U.S. Transmission segment provides interstate transmission, storage and gathering of natural gas. Substantially all of our operations are subject to the Federal Energy Regulatory Commission (FERC) and the Department of Transportation’s (DOT’s) rules and regulations. Our investments in Gulfstream Natural Gas System, LLC (Gulfstream), Southeast Supply Header, LLC (SESH) and Steckman Ridge, LP are included in U.S. Transmission.
The Liquids segment provides transportation of crude oil. The Express-Platte pipeline system (Express-Platte) is a crude oil pipeline system that connects Canadian and U.S. producers to refineries in the U.S. Rocky Mountain and Midwest regions. These operations are primarily subject to the rules and regulations of the FERC and the National Energy Board (NEB).
Our reportable segments offer different products and services and are managed separately as business units. Management evaluates segment performance based on earnings before interest, taxes, and depreciation and amortization (EBITDA). Cash, cash equivalents and investments are managed centrally, so the gains and losses on foreign currency remeasurement, and interest and dividend income, are excluded from the segments’ EBITDA. Our segment EBITDA may not be comparable to similarly titled measures of other companies because other companies may not calculate EBITDA in the same manner.
Business Segment Data
Condensed Consolidated Statements of Operations
Total Operating Revenues
 
Depreciation and Amortization
 
Segment EBITDA/Consolidated Earnings Before Income Taxes
 
(in millions)
Three Months Ended March 31, 2017
 
 
 
 
 
U.S. Transmission
$
596

 
$
77

 
$
479

Liquids
104

 
8

 
66

Total reportable segments
700

 
85

 
545

Other

 

 
(46
)
Depreciation and amortization

 

 
85

Interest expense

 

 
56

Interest income and other

 

 
1

Total consolidated
$
700

 
$
85

 
$
359

Three Months Ended March 31, 2016
 
 
 
 
 
U.S. Transmission
$
538

 
$
70

 
$
411

Liquids
86

 
7

 
56

Total reportable segments
624

 
77

 
467

Other

 

 
(20
)
Depreciation and amortization

 

 
77

Interest expense

 

 
56

Interest income and other

 

 
1

Total consolidated
$
624

 
$
77

 
$
315

    

11


3. Net Income Per Limited Partner Unit and Cash Distributions
The following table presents our net income per limited partner unit calculations:
 
 
 
Three Months Ended
March 31,
 
 
2017
 
2016
 
 
(in millions, except per unit amounts)
Net income—controlling interests
 
$
317

 
$
298

Less:
 
 
 
 
General partner’s interest in net income attributable to general partner units—2%
 
6

 
6

General partner’s interest in net income attributable to incentive distribution rights
 
83

 
63

Limited partners’ interest in net income attributable to common units
 
$
228

 
$
229

Weighted average limited partner units outstanding—basic and diluted
 
309

 
285

Net income per limited partner unit—basic and diluted
 
$
0.74

 
$
0.80

Our partnership agreement requires that, within 60 days after the end of each quarter, we distribute all of our Available Cash, as defined, to unitholders of record on the applicable record date.
Available Cash. Available Cash, for any quarter, consists of all cash and cash equivalents on hand at the end of that quarter:
less the amount of cash reserves established by the general partner to:
provide for the proper conduct of business,
comply with applicable law, any debt instrument or other agreement, or
provide funds for minimum quarterly distributions to the unitholders and to the general partner for any one or more of the next four quarters,
plus, if the general partner so determines, all or a portion of cash and cash equivalents on hand on the date of determination of Available Cash for the quarter.
Incentive Distribution Rights. The general partner holds incentive distribution rights beyond the first target distribution in accordance with the partnership agreement as follows:
 
 
 
Total Quarterly Distribution            
 
Marginal Percentage
Interest in Distributions
 
 
Target Per-Common Unit Amount
 
Common
Unitholders
 
General
Partner
Minimum Quarterly Distribution
 
$0.30
 
98
%
 
2
%
First Target Distribution
 
above $0.30 up to $0.345
 
98
%
 
2
%
Second Target Distribution
 
above $0.345 up to $0.375
 
85
%
 
15
%
Third Target Distribution
 
above $0.375 up to $0.45
 
75
%
 
25
%
Thereafter
 
above $0.45
 
50
%
 
50
%
To the extent these incentive distributions are made to the general partner, there will be more Available Cash proportionately allocated to our general partner than to holders of common units. A cash distribution of $0.70125 per limited partner unit was declared on May 4, 2017 and is payable on May 26, 2017 to unitholders of record at the close of business on May 15, 2017.
There is a reduction in the aggregate quarterly distributions, if any, to Spectra Energy, (as indirect holder of incentive distribution rights), by $4 million per quarter for a period of 12 consecutive quarters commencing with the quarter ending on December 31, 2015 through the quarter ending on September 30, 2018. The reduction of distributions is a result of the sale of our interests in DCP Sand Hills Pipeline, LLC (Sand Hills) and DCP Southern Hills Pipeline, LLC (Southern Hills) to Spectra Energy in October 2015.

12


4. Variable Interest Entities
Sabal Trail. In April 2016, NextEra Energy, Inc. (NextEra) purchased a 9.5% interest in Sabal Trail Transmission, LLC (Sabal Trail) from us. See Note 5 for additional information related to this transaction. As of March 31, 2017, we owned a 50% interest in Sabal Trail, a joint venture that is constructing a natural gas pipeline to transport natural gas to Florida. Sabal Trail is a variable interest entity (VIE) due to insufficient equity at risk to finance its activities. We determined that we are the primary beneficiary because we direct the activities of Sabal Trail that most significantly impact its economic performance and we consolidate Sabal Trail in our financial statements. The current estimate of the total remaining construction cost is approximately $0.7 billion.
The following summarizes assets and liabilities for Sabal Trail:
Condensed Consolidated Balance Sheets
March 31, 2017
 
December 31, 2016
 
(in millions)
Assets
 
 
 
Current assets
$
225

 
$
165

Net property, plant and equipment
2,552

 
1,942

Regulatory assets and deferred debits
100

 
79

Total Assets
$
2,877

 
$
2,186

Liabilities and Equity
 
 
 
Current liabilities
$
285

 
$
239

Equity
2,592

 
1,947

Total Liabilities and Equity
$
2,877

 
$
2,186

Nexus. We own a 50% interest in Nexus Gas Transmission, LLC (Nexus), a joint venture that is constructing a natural gas pipeline from Ohio to Michigan and continuing on to Ontario, Canada. Nexus is a VIE due to insufficient equity at risk to finance its activities. We determined that we are not the primary beneficiary because the power to direct the activities of Nexus that most significantly impact its economic performance is shared. We account for Nexus under the equity method. Our maximum exposure to loss is $1.0 billion. We have an investment in Nexus of $435 million and $356 million as of March 31, 2017 and December 31, 2016, respectively, classified as Investments in and Loans to Unconsolidated Affiliates on our Condensed Consolidated Balance Sheets.
In December 2016, we issued performance guarantees to a third party and an affiliate on behalf of Nexus. See Note 11 for further discussion of the guarantee arrangement.
5. Intangible Asset
During the first quarter of 2016 we entered into a project coordination agreement (PCA) with NextEra, Duke Energy Corporation and Williams Partners L.P. In accordance with the agreement, payments will be made, based on our proportional ownership interest in the Sabal Trail project, as certain milestones of the project are met. During the first quarter of 2016, the first milestone was achieved and paid, consisting of $48 million.
In April 2016, NextEra purchased an additional 9.5% interest in Sabal Trail, reducing our ownership interest in Sabal Trail to 50%. Upon purchase of the additional ownership interest, NextEra reimbursed us $8 million for NextEra’s proportional share of the first milestone payment, which reduced our total milestone payments to $40 million as of June 2016.
During the third quarter of 2016, the second milestone was achieved and paid, consisting of an additional payment of $40 million, for total milestone payments of $80 million as of March 31, 2017 . Both payments are classified as Cash Flows from Investing Activities — Purchase of Intangible, Net. This PCA is an intangible asset and is classified as Investments and Other Assets — Other on our Condensed Consolidated Balance Sheet. The intangible asset will be amortized over a period of 25 years beginning at the time of in-service of Sabal Trail, which is expected to occur during the second quarter of 2017.
6. Marketable Securities and Restricted Funds
We routinely invest excess cash and various restricted balances in securities such as commercial paper, corporate debt securities, and other money market securities in the United States, as well as equity securities in Canada. We do not purchase marketable securities for speculative purposes, therefore we do not have any securities classified as trading securities. While we

13


do not routinely sell marketable securities prior to their scheduled maturity dates, some of our investments may be held and restricted for the purposes of funding future capital expenditures and NEB regulatory requirements, so these investments are classified as available-for-sale (AFS) marketable securities as they may occasionally be sold prior to their scheduled maturity dates due to the unexpected timing of cash needs. Initial investments in securities are classified as purchases of the respective type of securities (AFS marketable securities or held-to-maturity (HTM) marketable securities). Maturities of securities are classified within proceeds from sales and maturities of securities in the Condensed Consolidated Statements of Cash Flows. 
AFS Securities. We had $2 million and $10 million of AFS securities classified as Investments and Other Assets — Other on the Condensed Consolidated Balance Sheets as of March 31, 2017 and December 31, 2016, respectively. These investments include $2 million and $1 million of restricted funds held and collected from customers for Canadian pipeline abandonment in accordance with the NEB's regulatory requirements, as of March 31, 2017 and December 31, 2016, respectively, as well as $9 million of restricted funds related to certain construction projects as of December 31, 2016.
At March 31, 2017, the weighted-average contractual maturity of outstanding AFS securities was less than one year.
There were no material gross unrecognized holding gains or losses associated with investments in AFS securities at March 31, 2017 or December 31, 2016.
HTM Securities. All of our HTM securities are restricted funds. We had $4 million and $3 million of money market securities classified as Current Assets — Other on the Condensed Consolidated Balance Sheets as of March 31, 2017 and December 31, 2016, respectively. These securities are restricted pursuant to certain Express-Platte debt agreements.
At March 31, 2017, the weighted-average contractual maturity of outstanding HTM securities was less than one year.
There were no material gross unrecognized holding gains or losses associated with investments in HTM securities at March 31, 2017 or December 31, 2016.
Other Restricted Funds. In addition to the AFS and HTM securities that were restricted funds as described above, we had other restricted funds totaling $3 million and $5 million classified as Investments and Other Assets — Other on the Condensed Consolidated Balance Sheets at March 31, 2017 and December 31, 2016, respectively. These restricted funds are related to certain construction projects.
Changes in restricted balances are presented within Cash Flows from Investing Activities on our Condensed Consolidated Statements of Cash Flows.
7. Debt and Credit Facility
Available Credit Facility and Restricted Debt Covenants
 
 
Expiration Date
 
Total Credit Facility Capacity
 
Commercial
Paper Outstanding at
March 31, 2017
 
Available
Credit Facility
Capacity
 
 
 
 
(in millions)
Spectra Energy Partners, LP
 
2021
 
$
2,500

 
$
1,051

 
$
1,449

The issuances of commercial paper, letters of credit and revolving borrowings reduce the amount available under the credit facility. As of March 31, 2017, there were no letters of credit issued or revolving borrowings outstanding under the credit facility.
Our credit agreements contain various covenants, including the maintenance of a consolidated leverage ratio, as defined in the agreements. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements. As of March 31, 2017, we were in compliance with those covenants. In addition, our credit agreements allow for acceleration of payments or termination of the agreements due to nonpayment, or in some cases, due to the acceleration of our other significant indebtedness or other significant indebtedness of some of our subsidiaries. Our debt and credit agreements do not contain provisions that trigger an acceleration of indebtedness based solely on the occurrence of a material adverse change in our financial condition or results of operations.
As noted above, the terms of our credit agreements require us to maintain a ratio of total Consolidated Indebtedness-to-Consolidated EBITDA, as defined in the agreement, of 5.0 to 1 or less. As of March 31, 2017, this ratio was 4.1 to 1.

14


8. Fair Value Measurements
The following presents, for each of the fair value hierarchy levels, assets that are measured at fair value on a recurring basis as of March 31, 2017 and December 31, 2016:
Description
Condensed Consolidated Balance Sheet Caption
 
March 31, 2017
Total
 
Level 1
 
Level 2
 
Level 3
 
 
 
(in millions)
Corporate debt securities
Cash and cash equivalents
 
$
199

 
$

 
$
199

 
$

Canadian equity securities
Investments and other assets — other
 
2

 
2

 

 

Interest rate swaps
Investments and other assets — other
 
8

 

 
8

 

Total Assets
 
$
209

 
$
2

 
$
207

 
$


Description
Condensed Consolidated Balance Sheet Caption
 
December 31, 2016
Total
 
Level 1
 
Level 2
 
Level 3
 
 
 
(in millions)
Corporate debt securities
Cash and cash equivalents
 
$
145

 
$

 
$
145

 
$

Corporate debt securities
Investments and other assets — other
 
9

 

 
9

 

Canadian equity securities
Investments and other assets — other
 
1

 
1

 

 

Interest rate swaps
Investments and other assets — other
 
9

 

 
9

 

Total Assets
 
$
164

 
$
1

 
$
163

 
$

Level 1
Level 1 valuations represent quoted unadjusted prices for identical instruments in active markets.
Level 2 Valuation Techniques
Fair values of our financial instruments that are actively traded in the secondary market, including our long-term debt, are determined based on market-based prices. These valuations may include inputs such as quoted market prices of the exact or similar instruments, broker or dealer quotations, or alternative pricing sources that may include models or matrix pricing tools, with reasonable levels of price transparency.
For interest rate swaps, we utilize data obtained from a third-party source for the determination of fair value. Both the future cash flows for the fixed-leg and floating-leg of our swaps are discounted to present value.
Level 3 Valuation Techniques
Level 3 valuation techniques include the use of pricing models, discounted cash flow methodologies or similar techniques where at least one significant model assumption or input is unobservable. Level 3 financial instruments also include those for which the determination of fair value requires significant management judgment or estimation.
Financial Instruments
The fair values of financial instruments that are recorded and carried at book value are summarized in the following table. Judgment is required in interpreting market data to develop the estimates of fair value. These estimates are not necessarily indicative of the amounts we could have realized in current markets.
 
 
March 31, 2017
 
December 31, 2016
 
 
Book
Value
 
Approximate
Fair Value
 
Book
Value
 
Approximate
Fair Value
 
 
(in millions)
Note receivable, noncurrent (a)
 
$
71

 
$
71

 
$
71

 
$
71

Long-term debt, including current maturities (b)
 
6,662

 
6,826

 
6,672

 
6,855

________ 
(a)
Included within Investments in and Loans to Unconsolidated Affiliates.
(b)
Excludes commercial paper, unamortized items and fair value hedge carrying value adjustments.

15


The fair value of our long-term debt is determined based on market-based prices as described in the Level 2 valuation technique described above and is classified as Level 2.
The fair values of cash and cash equivalents, restricted cash, short-term investments, accounts receivable, note receivable-noncurrent, accounts payable, commercial paper and short-term money market securities are not materially different from their carrying amounts because of the short-term nature of these instruments or because the stated rates approximate market rates.
During the three months ended March 31, 2017 and 2016, there were no material adjustments to assets and liabilities measured at fair value on a nonrecurring basis.
9. Risk Management and Hedging Activities
Changes in interest rates expose us to risk as a result of our issuance of variable and fixed-rate debt and commercial paper. We are exposed to foreign currency risk from the Canadian portion of Express-Platte. We employ established policies and procedures to manage our risks associated with these market fluctuations, which may include the use of derivatives, mostly around interest rate exposures. For interest rate derivative instruments that are designated and qualify as fair value hedges, the gain or loss on the derivative as well as the offsetting loss or gain on the hedged item attributable to the hedged risk is recognized in the Condensed Consolidated Statements of Operations. There were no significant amounts of gains or losses recognized in net income during the three months ended March 31, 2017.

At March 31, 2017, we had “pay floating — receive fixed” interest rate swaps outstanding with a total notional amount of $900 million to hedge against changes in the fair value of our fixed-rate debt that arise as a result of changes in market interest rates. These swaps also allow us to transform a portion of the underlying interest payments related to our long-term fixed-rate debt securities into variable-rate interest payments in order to achieve our desired mix of fixed and variable-rate debt.

Information about our interest rate swaps that had netting or rights of offset arrangements are as follows:
 
March 31, 2017
 
December 31, 2016
 
Gross Amounts
Presented in
the Condensed
Consolidated
Balance Sheet
 
Amounts Not
Offset in the
Condensed
Consolidated
Balance Sheet
 
Net
Amount
 
Gross Amounts
Presented in
the Condensed
Consolidated
Balance Sheet
 
Amounts Not
Offset in the
Condensed
Consolidated
Balance Sheet
 
Net
Amount
Description
(in millions)
Assets
$
8

 
$

 
$
8

 
$
9

 
$

 
$
9

10. Commitments and Contingencies
Environmental
We are subject to various federal, state and local laws and regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. These laws and regulations can change from time to time, imposing new obligations on us.
Like others in the energy industry, we and our affiliates are responsible for environmental remediation at various contaminated sites. These include some properties that are part of our ongoing operations, sites formerly owned or used by us, and sites owned by third parties. Remediation typically involves management of contaminated soils and may involve groundwater remediation. Managed in conjunction with relevant federal, state/provincial and local agencies, activities vary with site conditions and locations, remedial requirements, complexity and sharing of responsibility. If remediation activities involve statutory joint and several liability provisions, strict liability, or cost recovery or contribution actions, we or our affiliates could potentially be held responsible for contamination caused by other parties. In some instances, we may share liability associated with contamination with other potentially responsible parties, and may also benefit from contractual indemnities that cover some or all cleanup costs. All of these sites generally are managed in the normal course of business or affiliated operations.
Litigation
Litigation and Legal Proceedings. We are involved in legal, tax and regulatory proceedings in various forums arising in the ordinary course of business, including matters regarding contract and payment claims, some of which involve substantial monetary amounts. We have insurance coverage for certain of these losses should they be incurred. We believe that the final

16


disposition of these proceedings will not have a material effect on our consolidated results of operations, financial position or cash flows.
Legal costs related to the defense of loss contingencies are expensed as incurred. We had no material reserves for legal matters recorded as of March 31, 2017 or December 31, 2016 related to litigation.

11. Guarantees
We have various financial guarantees which are issued in the normal course of business. We enter into these arrangements to facilitate a commercial transaction with a third party by enhancing the value of the transaction to the third party. To varying degrees, these guarantees involve elements of performance and credit risk, which are not included on our Condensed Consolidated Balance Sheets. The possibility of having to perform under these guarantees is largely dependent upon future operations of various subsidiaries, investees and other third parties, or the occurrence of certain future events.
In December 2016, we issued performance guarantees to a third party and an affiliate on behalf of an equity method investee. These guarantees were issued to enable the equity method investee to enter into long-term transportation contracts with the third party. While the likelihood is remote, the maximum potential amount of future payments we could have been required to make as of March 31, 2017 was $61 million. These performance guarantees expire in 2032.
As of March 31, 2017, the amounts recorded for the guarantees described above are not material, both individually and in the aggregate.
12. Issuances of Common Units
During the three months ended March 31, 2017, we issued 0.8 million common units to the public under our at-the-market program, and approximately 17,000 general partner units to our general partner in order for it to maintain a 2% general partner interest. Total net proceeds were $39 million, including approximately $1 million of proceeds from our general partner.
13. New Accounting Pronouncements
In October 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control,” to amend the consolidation guidance on how a reporting entity that is the single decision maker of a VIE should treat indirect interests in the entity held through related parties that are under common control with the reporting entity when determining whether it is the primary beneficiary of that VIE. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In March 2016, the FASB issued ASU No. 2016-07, “Investments—Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting,” which eliminates the requirement to apply the equity method of accounting retrospectively when a reporting entity obtains significant influence over a previously held investment. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In March 2016, the FASB issued ASU No. 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments,” which simplifies the embedded derivative analysis for debt instruments containing contingent call or put options. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In March 2016, the FASB issued ASU No. 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships,” which clarifies the hedge accounting impact when there is a change in one of the counterparties to the derivative contract (i.e. novation). We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In July 2015, the FASB issued ASU No. 2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory,” which simplifies the subsequent measurement of inventory by requiring inventory to be measured at the lower of cost and net realizable value. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In February 2017, the FASB issued ASU No. 2017-05, “Other Income—Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20): Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales

17


of Nonfinancial Assets,” to clarify the scope of asset derecognition guidance and accounting for partial sales of nonfinancial assets. The ASU also clarifies the scope provisions of nonfinancial assets, how to allocate consideration to each distinct asset, and amends the guidance for derecognition of a distinct nonfinancial asset in partial sale transactions. This ASU is effective for us on January 1, 2018 and allows for either full retrospective or modified retrospective adoption. We are currently evaluating this ASU and its potential impact on us.

In January 2017, the FASB issued ASU No. 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment,” to simplify the subsequent measurement of goodwill. Under the new guidance, goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. We early adopted this standard on January 1, 2017 with no material impact on our consolidated operations, financial position, or cash flows.

In January 2017, the FASB issues ASU No. 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business,” to add guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (disposals) of assets or businesses. We early adopted this standard on January 1, 2017 with no material impact on our consolidated operations, financial position, or cash flows.

In November 2016, the FASB issued ASU No. 2016-18, “Statement of Cash Flows (Topic 230): Restricted Cash,” to address the diversity in the classification and presentation of changes in restricted cash and restricted cash equivalents on the statement of cash flows. The update requires that restricted cash and restricted cash equivalents be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This ASU is effective for us on January 1, 2018. We are currently evaluating this ASU and its potential impact on us.

In August 2016, the FASB issued ASU No. 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments,” to provide guidance on specific cash flow issues with the objective of reducing the existing diversity in practice. This ASU is effective for us on January 1, 2018. We are currently evaluating this ASU and its potential impact on us.

In June 2016, the FASB issued ASU No. 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” to provide financial statement users with more useful information about the expected credit losses on financial instruments and other commitments to extend credit held by a reporting entity at each reporting date. Current treatment uses the incurred loss methodology for recognizing credit losses that delays the recognition until it is probable a loss has been incurred. The amendment adds a new impairment model, known as the current expected credit loss model that is based on expected losses rather than incurred losses. Under the new guidance, an entity recognizes as an allowance its estimate of expected credit losses, which the FASB believes will result in more timely recognition of such losses. This ASU is effective for us on January 1, 2020. We are currently evaluating this ASU and its potential impact on us.

In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842),” to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on our consolidated statements of financial position and disclosing additional key information about lease agreements. This ASU is effective for us on January 1, 2019. We are currently evaluating this ASU and its potential impact on us.

In January 2016, the FASB issued ASU No. 2016-01, “Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities,” to amend the classification and measurement of financial instruments. Changes primarily affect the accounting for equity investments, financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. This ASU is effective for us on January 1, 2018. Early adoption is not permitted. We are currently evaluating this ASU and its potential impact on us.

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” to significantly enhance consistency and comparability of revenue recognition practices across entities and industries. The new standard establishes a single, principles-based five-step model to be applied to all contracts with customers and introduces new and enhanced disclosure requirements. Since its release, the FASB has issued multiple amendments clarifying and/or amending ASU No. 2014-09. This ASU is effective for us on January 1, 2018 and allows for either full retrospective or modified retrospective adoption. We have substantially completed a review of contracts with customers in relation to the requirements of ASU No. 2014-09. While we have not identified any material difference in the amount or timing of revenue recognition for the categories we have reviewed to date, our evaluation is not complete and we have not concluded on the overall impacts of adopting this standard. In addition, we are in the process of implementing appropriate changes to our business processes, systems and controls to support the recognition and disclosure requirements under the new standard.

18


Item 2.
Management’s Discussion and Analysis of Financial Condition and Results of Operations.
INTRODUCTION
Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the accompanying Condensed Consolidated Financial Statements.
EXECUTIVE OVERVIEW
For the three months ended March 31, 2017 and 2016, we reported net income from controlling interests of $317 million and $298 million, respectively.
The highlights for the three months ended March 31, 2017 included increased earnings driven by expansion, mainly on Algonquin Gas Transmission, LLC (Algonquin) and Texas Eastern Transmission, LP (Texas Eastern), higher transportation revenues due to higher volumes of heavy oil on the Express pipeline and expansion revenues from the Express Enhancement project placed into service in October 2016, partially offset by merger-related severance costs.
For the three months ended March 31, 2017 and 2016, distributable cash flow was $356 million and $371 million, respectively.
A cash distribution of $0.70125 per limited partner unit was declared on May 4, 2017 and is payable on May 26, 2017. We intend to increase our quarterly distribution by one and a quarter cents per unit each quarter through 2017. Our Board of Directors evaluates each distribution decision within the confines of the Partnership agreement and based on an assessment of growth in distributable cash flow.
For the three months ended March 31, 2017, we had $808 million of capital and investment expenditures. We currently project $2.6 billion of capital and investment expenditures for the full year, including expansion capital expenditures of $2.3 billion. These projections exclude contributions from noncontrolling interests.

We are committed to an investment-grade balance sheet and continued prudent financial management of our capital structure. Therefore, financing growth activities will continue to be based on our strong and growing fee-based earnings and cash flows, the issuances of debt and equity securities as well as return of capital from joint venture asset-level financings. As of March 31, 2017, we have access to a $2.5 billion revolving credit facility which is used principally as a back-stop for our commercial paper program.

On February 27, 2017, Enbridge and Spectra Energy completed the Merger pursuant to which Spectra Energy merged with and into a direct, wholly owned subsidiary of Enbridge, with Spectra Energy continuing as the surviving corporation and a wholly owned subsidiary of Enbridge, and each outstanding share of common stock of Spectra Energy was automatically converted into, and became exchangeable for, 0.984 of Enbridge common share. As a result of the Merger, we became an indirect subsidiary of Enbridge through Enbridge’s ownership of Spectra Energy.


19


RESULTS OF OPERATIONS
 
Three Months Ended
March 31,
 
2017
 
2016
 
(in millions)
Operating revenues
$
700

 
$
624

Operating expenses
368

 
300

Operating income
332

 
324

Earnings from equity investments
38

 
27

Other income and expenses, net
45

 
20

Interest expense
56

 
56

Earnings before income taxes
359

 
315

Income tax expense
5

 
4

Net income
354

 
311

Net income—noncontrolling interests
37

 
13

Net income—controlling interests
$
317

 
$
298

Operating Revenues. The $76 million increase was driven mainly by:
revenues from expansion projects, primarily on Algonquin and Texas Eastern, and
higher transportation revenues due to higher volumes of heavy oil on the Express pipeline and the Express Enhancement expansion project placed into service in October 2016, partially offset by
lower recoveries of electric power and other costs passed through to gas transmission customers.
Operating Expenses. The $68 million increase was driven mainly by:
merger-related severance costs and
higher costs related to expansion, partially offset by
lower electric power and other costs passed through to gas transmission customers.
Other Income and Expenses, Net. The $25 million increase was mainly attributable to higher allowance for funds used during construction (AFUDC) due to higher capital spending on expansion projects.
Segment Results
Management evaluates segment performance based on EBITDA. Cash, cash equivalents and investments are managed centrally, so the gains and losses on foreign currency remeasurement, and interest and dividend income, are excluded from the segments’ EBITDA. We consider segment EBITDA to be a good indicator of each segment’s operating performance from its continuing operations, as it represents the results of our operations without regard to financing methods or capital structures. Our segment EBITDA may not be comparable to similarly titled measures of other companies because other companies may not calculate EBITDA in the same manner.

20


Segment EBITDA is summarized in the following table. Detailed discussions follow.
EBITDA by Business Segment
 
Three Months Ended
March 31,
 
2017
 
2016
 
(in millions)
U.S. Transmission
$
479

 
$
411

Liquids
66

 
56

Total reportable segment EBITDA
545

 
467

Other
(46
)
 
(20
)
Total reportable segment and other EBITDA
499

 
447

Depreciation and amortization
85

 
77

Interest expense
56

 
56

Interest income and other
1

 
1

Earnings before income taxes
$
359

 
$
315

The amounts discussed below are after eliminating intercompany transactions.
U.S. Transmission
 
Three Months Ended
March 31,
 
2017
 
2016
 
Increase (Decrease)
 
(in millions)
Operating revenues
$
596

 
$
538

 
$
58

Operating expenses
 
 
 
 
 
     Operating, maintenance and other
200

 
172

 
28

Other income and expenses
83

 
45

 
38

EBITDA
$
479

 
$
411

 
$
68

 
 
 
 
 
 
Operating Revenues. The $58 million increase was driven by:
a $62 million increase due to expansion, primarily on Algonquin and Texas Eastern, and
a $2 million increase in storage revenues due to new contracts at higher rates, partially offset by
a $5 million decrease in recoveries of electric power and other costs passed through to gas transmission customers and
a $3 million decrease in natural gas transportation revenues mainly from firm transportation on Algonquin and Texas Eastern.
Operating Expenses. The $28 million increase was driven by:
$18 million of merger-related severance costs,
a $12 million increase in costs related to expansion and
a $2 million increase due to pipeline inspection and repair costs related to the 2016 Texas Eastern pipeline incident, partially offset by
a $5 million decrease in electric power and other costs passed through to gas transmission customers.
Other Income and Expenses. The $38 million increase was mainly due to higher AFUDC resulting from higher capital spending on expansion projects.

21


Liquids
 
Three Months Ended
March 31,
 
2017
 
2016
 
Increase (Decrease)
 
(in millions)
Operating revenues
$
104

 
$
86

 
$
18

Operating expenses
 
 
 
 
 
     Operating, maintenance and other
37

 
31

 
6

Other income and expenses
(1
)
 
1

 
(2
)
EBITDA
$
66

 
$
56

 
$
10

Express pipeline revenue receipts, MBbl/d (a)
271

 
233

 
38

Platte PADD II deliveries, MBbl/d
146

 
124

 
22

_______
(a)    Thousand barrels per day.
Operating Revenues. The $18 million increase in operating revenues was driven by:
a $9 million increase in transportation revenues as a result of higher Express pipeline volumes of heavy oil and
a $7 million increase in transportation revenues due to the Express Enhancement expansion project placed into service in October 2016.
Operating Expenses. The $6 million increase in operating expenses was mainly driven by:
a $3 million increase in power costs primarily due to higher usage and
$2 million of merger-related severance costs.
Other
 
Three Months Ended
March 31,
 
2017
 
2016
 
Increase (Decrease)
 
(in millions)
Operating expenses
$
46

 
$
20

 
$
26

EBITDA
$
(46
)
 
$
(20
)
 
$
(26
)
Operating Expenses. The $26 million increase primarily reflects merger-related severance costs.


22


Distributable Cash Flow
We define Distributable Cash Flow as EBITDA plus
distributions from equity investments,
other non-cash items affecting net income, less
earnings from equity investments,
interest expense,
equity AFUDC,
net cash paid for income taxes,
distributions to noncontrolling interests, and
maintenance capital expenditures.
Distributable Cash Flow does not reflect changes in working capital balances. Distributable Cash Flow should not be viewed as indicative of the actual amount of cash that we plan to distribute for a given period.
Distributable Cash Flow is the primary financial measure used by our management and by external users of our financial statements to assess the amount of cash that is available for distribution.
Distributable Cash Flow is a non-GAAP measure and should not be considered an alternative to Net Income, Operating Income, cash from operations or any other measure of financial performance or liquidity presented in accordance with GAAP. Distributable Cash Flow excludes some, but not all, items that affect Net Income and Operating Income and these measures may vary among other companies. Therefore, Distributable Cash Flow as presented may not be comparable to similarly titled measures of other companies.
Significant drivers of variances in Distributable Cash Flow between the periods presented are substantially the same as those previously discussed under Results of Operations. Other drivers include the timing of certain cash outflows, such as capital expenditures for maintenance.

23


Reconciliation of Net Income to Non-GAAP “Distributable Cash Flow”
 
 
Three Months Ended
March 31,
 
2017
 
2016
 
(in millions)
Net income
$
354

 
$
311

Add:
 
 
 
Interest expense
56

 
56

Income tax expense
5

 
4

Depreciation and amortization
85

 
77

Foreign currency (gain) loss

 
(1
)
Less:
 
 
 
Third party interest income
1

 

EBITDA
499

 
447

Add:
 
 
 
Earnings from equity investments
(38
)
 
(27
)
Distributions from equity investments
38

 
65

Other
1

 
2

Less:
 
 
 
Interest expense
56

 
56

Equity AFUDC
45

 
17

Net cash paid for income taxes
5

 
1

Distributions to noncontrolling interests
12

 
7

Maintenance capital expenditures
26

 
35

Distributable Cash Flow
$
356

 
$
371



24


LIQUIDITY AND CAPITAL RESOURCES
As of March 31, 2017, we had negative working capital of $1,514 million. This balance includes commercial paper liabilities totaling $1,051 million and current maturities of long-term debt of $415 million. We will rely upon cash flows from operations, including cash distributions received from our equity affiliates, and various financing transactions, which may include debt and/or equity issuances, to fund our liquidity and capital requirements for the next 12 months. We have access to a revolving credit facility, with available capacity of $1,449 million at March 31, 2017. This facility is used principally as a back-stop for our commercial paper program, which is used to manage working capital requirements and for temporary funding of capital expenditures. We expect to be self-funding and plan to continue to pursue expansion opportunities over the next several years. Capital resources may continue to include commercial paper, short-term borrowings under our current credit facility and possibly securing additional sources of capital including debt and/or equity as well as return of capital from joint venture asset-level financings. See Note 7 of Notes to Condensed Consolidated Financial Statements for a discussion of the available credit facility and Financing Cash Flows and Liquidity for a discussion of effective shelf registrations.
Cash Flow Analysis
The following table summarizes the changes in cash flows for each of the periods presented:
 
 
Three Months Ended
March 31,
 
 
2017
 
2016
 
 
(in millions)
Net cash provided by (used in):
 
 
 
 
Operating activities
 
$
364

 
$
297

Investing activities
 
(788
)
 
(508
)
Financing activities
 
490

 
257

Net increase in cash and cash equivalents
 
66

 
46

Cash and cash equivalents at beginning of the period
 
216

 
168

Cash and cash equivalents at end of the period
 
$
282

 
$
214

Operating Cash Flows
Net cash provided by operating activities increased $67 million to $364 million in the three months ended March 31, 2017 compared to the same period in 2016, driven mainly by higher earnings and changes in working capital.
Investing Cash Flows
Net cash used in investing activities increased $280 million to $788 million in the three months ended March 31, 2017 compared to the same period in 2016. The change was mainly driven by increased capital and investment expenditures.
Capital and Investment Expenditures by Business Segment
 
 
Three Months Ended
March 31,
 
 
2017
 
2016
 
 
(in millions)
U.S. Transmission
 
$
802

 
$
479

Liquids
 
6

 
16

Total consolidated
 
$
808

 
$
495

Capital and investment expenditures for the three months ended March 31, 2017 consisted of $782 million for expansion projects and $26 million for maintenance and other projects.
We project 2017 capital and investment expenditures of approximately $2.6 billion, consisting of $2.3 billion of expansion capital expenditures and $0.3 billion for maintenance and upgrades of existing plants, pipelines and infrastructure to serve growth. These projections exclude contributions from noncontrolling interests.

25


Financing Cash Flows and Liquidity
Net cash provided by financing activities increased $233 million to $490 million in the three months ended March 31, 2017 compared to the same period in 2016. The change was mainly driven by:
a $195 million increase in contributions from noncontrolling interests and
a $147 million increase in issuances of commercial paper, partially offset by
a $51 million increase in distributions to partners and
a $43 million decrease in proceeds from issuances of units.
During the three months ended March 31, 2017, we issued 0.8 million common units to the public under our at-the-market program and approximately 17,000 general partner units to our general partner in order for it to maintain a 2% general partner interest. Total net proceeds were $39 million, including approximately $1 million of proceeds from Spectra Energy. The net proceeds were used for general partnership purposes, which may have included debt repayment, capital expenditures and/or additions to working capital. In 2017, we have issued 1 million common units to the public under our at-the-market program and approximately 21,000 general partner units to our general partner in order for it to maintain a 2% general partner interest, for total net proceeds of approximately $48 million, including $1 million of proceeds from Spectra Energy.
Available Credit Facility and Restrictive Debt Covenants. See Note 7 of Notes to Condensed Consolidated Financial Statements for a discussion of the available credit facility and related financial and other covenants.
Cash Distributions. A cash distribution of $0.70125 per limited partner unit was declared on May 4, 2017, payable on May 26, 2017, representing the thirty-eighth consecutive quarterly increase.
Other Financing Matters. We have an effective shelf registration statement on file with the Securities and Exchange Commission (SEC) to register the issuance of unspecified amounts of limited partner common units and various debt securities and another registration statement on file with the SEC to register the issuance of $1 billion, in the aggregate, of limited partner units over time. This registration has $321 million available as of March 31, 2017.


26


OTHER ISSUES
New Accounting Pronouncements. See Note 13 of Notes to Condensed Consolidated Financial Statements for discussion.
Item 3.
Quantitative and Qualitative Disclosures about Market Risk.
Our exposure to market risk is described in Item 7A of our Annual Report on Form 10-K, for the year ended December 31, 2016. We believe our exposure to market risk has not changed materially since then.
Item 4.
Controls and Procedures.
Evaluation of Disclosure Controls and Procedures
Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed by us in the reports we file or submit under the Securities Exchange Act of 1934 (Exchange Act) is recorded, processed, summarized, and reported, within the time periods specified by the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed by us in the reports we file or submit under the Exchange Act is accumulated and communicated to management, including the Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.
Under the supervision and with the participation of the management of Spectra Energy Partners (DE) GP, LP (our General Partner), including the Chief Executive Officer and Chief Financial Officer, we have evaluated the effectiveness of our disclosure controls and procedures (as such term is defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act) as of March 31, 2017, and, based upon this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that these controls and procedures are effective at the reasonable assurance level.
Changes in Internal Control over Financial Reporting
Under the supervision and with the participation of the management of our General Partner, including the Chief Executive Officer and Chief Financial Officer, we have evaluated changes in internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the fiscal quarter ended March 31, 2017 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

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PART II. OTHER INFORMATION
Item 1.
Legal Proceedings.
We have no material pending legal proceedings that are required to be disclosed hereunder. For information regarding other legal proceedings and environmental matters, see Note 10 of Notes to Condensed Consolidated Financial Statements, which information is incorporated by reference into this Part II.
Item 1A.
Risk Factors.
In addition to the other information set forth in this report, careful consideration should be given to the factors discussed in Part I, “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2016, which could materially affect our financial condition or future results. There have been no material changes to those risk factors.
Item 5.
Other Information.
On May 4, 2017, Stephen J. Neyland, 49, was appointed as the Vice PresidentFinance of Spectra Energy Partners GP, LLC, the general partner of Spectra Energy Partners (DE) GP, LP, which is the general partner of Spectra Energy Partners, LP (the Partnership).  Mr. Neyland also serves as Vice PresidentFinance of Enbridge Energy Partners, L.P.’s general partner and of Enbridge Energy Management, L.L.C. (collectively, the Enbridge Affiliates) since October 2010. Mr. Neyland previously served the Enbridge Affiliates as Controller from 2006 to 2010, ControllerNatural Gas from January 2005, Assistant Controller from May 2004 to January 2005 and in other managerial roles in finance and accounting from December 2001 to May 2004. Prior to joining Enbridge, Mr. Neyland was Controller of Koch Midstream Services from 1999 to 2001.  Mr. Neyland does not have an employment contract with the Partnership. The Partnership does not directly employ the officers of the General Partner and does not have control over their compensation.
Item 6.
Exhibits.
Any agreements included as exhibits to this Form 10-Q may contain representations and warranties by each of the parties to the applicable agreement. These representations and warranties have been made solely for the benefit of the other parties to the applicable agreement and:
were not intended to be treated as categorical statements of fact, but rather as a way of allocating the risk to one of the parties if those statements prove to be inaccurate;
may have been qualified by disclosures that were made to the other party in connection with the negotiation of the applicable agreement;
may apply contract standards of “materiality” that are different from “materiality” under the applicable securities laws; and
were made only as of the date of the applicable agreement or such other date or dates as may be specified in the agreement.
We acknowledge that, notwithstanding the inclusion of the foregoing cautionary statements, we are responsible for considering whether additional specific disclosures of material information regarding material contractual provisions are required to make the statements in this Form 10-Q not misleading.

28


(a) Exhibits
 
 
Exhibit
Number
  
 
 
 
 
 
 
*31.1
  
Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
*31.2
  
Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
*32.1
  
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
*32.2
  
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
*101.INS
  
XBRL Instance Document.
 
 
*101.SCH
  
XBRL Taxonomy Extension Schema.
 
 
*101.CAL
  
XBRL Taxonomy Extension Calculation Linkbase.
 
 
*101.DEF
  
XBRL Taxonomy Extension Definition Linkbase.
 
 
*101.LAB
  
XBRL Taxonomy Extension Label Linkbase.
 
 
*101.PRE
  
XBRL Taxonomy Extension Presentation Linkbase.

*
Filed herewith

The total amount of securities of the registrant or its subsidiaries authorized under any instrument with respect to long-term debt not filed as an exhibit does not exceed 10% of the total assets of the registrant and its subsidiaries on a consolidated basis. The registrant agrees, upon request of the Securities and Exchange Commission, to furnish copies of any or all of such instruments to it.


29


SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

 
 
 
 
 
 
 
SPECTRA ENERGY PARTNERS, LP
 
 
 
 
 
 
By:
 
Spectra Energy Partners (DE) GP, LP,
its general partner
 
 
 
 
 
 
By:
 
Spectra Energy Partners GP, LLC,
its general partner
 
 
 
 
Date: May 10, 2017
 
By:
 
/S/    William T. Yardley       
 
 
 
 
William T. Yardley
President and Chairman of the Board
 
 
 
 
Date: May 10, 2017
 
By:
 
/S/    Stephen J. Neyland        
 
 
 
 
Stephen J. Neyland
Vice President—Finance

30